US20100084146A1 - Ball seat sub - Google Patents
Ball seat sub Download PDFInfo
- Publication number
- US20100084146A1 US20100084146A1 US12/572,062 US57206209A US2010084146A1 US 20100084146 A1 US20100084146 A1 US 20100084146A1 US 57206209 A US57206209 A US 57206209A US 2010084146 A1 US2010084146 A1 US 2010084146A1
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- United States
- Prior art keywords
- actuator member
- downhole tool
- bore
- inner diameter
- elongated body
- Prior art date
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- 239000012530 fluid Substances 0.000 claims abstract description 46
- 238000000429 assembly Methods 0.000 claims abstract description 7
- 238000000034 method Methods 0.000 claims description 15
- 230000007704 transition Effects 0.000 claims description 9
- 238000010008 shearing Methods 0.000 claims description 6
- 230000013011 mating Effects 0.000 claims description 3
- 230000008878 coupling Effects 0.000 claims 1
- 238000010168 coupling process Methods 0.000 claims 1
- 238000005859 coupling reaction Methods 0.000 claims 1
- 230000007246 mechanism Effects 0.000 description 15
- 239000004568 cement Substances 0.000 description 5
- 230000004913 activation Effects 0.000 description 3
- 230000008901 benefit Effects 0.000 description 3
- 229920001971 elastomer Polymers 0.000 description 2
- 239000000806 elastomer Substances 0.000 description 2
- 230000003213 activating effect Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000003466 welding Methods 0.000 description 1
Images
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
- E21B34/142—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools unsupported or free-falling elements, e.g. balls, plugs, darts or pistons
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
Definitions
- Embodiments disclosed herein relate to downhole tools, particularly setting tools for hydraulic liners and other hydraulic actuated devices. More specifically, embodiments disclosed herein relate to setting tools that actuate hydraulic liner hangers in deviated wellbores.
- liners are used below casing in wellbores to extend the length of the casing.
- a liner is a section of smaller casing that is suspended downhole in existing casing. In most cases, the liner extends downwardly into an open hole and overlaps the existing casing by approximately 200-400 ft. In certain application, the liner may be cemented in place.
- a conventional liner hanger is used to attach or hang liners from the internal wall of a casing segment. Hydraulic liner hangers have been preferred by operators in deviated wellbores over mechanical liner hangers. This is because deviation of the wellbore makes it less certain that the mechanical hanger mechanism will be properly actuated in a deviated wellbore. In this instance hydraulic liners provide advantages over mechanical hangers, because hydraulic hangers may not require mechanical movement of the pipe or tubular.
- Some aspects of using a conventional setting tool may lengthen the time required to complete the placement and cementing of a liner.
- other setting tool designs are subject to inadvertent damage within the tool.
- collet-type valve seats have been used in applications where the drop ball seats on relatively short upwardly directed collet fingers, thus compressing the collet fingers when the ball is seated.
- a shear pin release permits a shift of the fingers to a location where the collet fingers are expanded to release the ball member.
- the collet fingers are typically short, thereby preventing the compressive forces from damaging them. (The design, thus, requires that the fingers have little resilience and prevents them from fully expanding unless a large diameter ball is used.
- valve seat has a convex upper surface, as shown in, for example, U.S. Pat. No. 5,553,672.
- gravity may move the ball into a dead fluid area that is adjacent to the seat.
- the ball In order to seat the drop ball, the ball must be lifted off of the low side of the tool and moved to the center of the valve with the fluid flow. This process can be time constraining and difficult to accomplish.
- embodiments disclosed herein relate to a downhole tool for providing a pressure differential between sub-assemblies, the downhole tool including an elongated body, a tubular assembly disposed within the elongated body, the tubular assembly including a central flowbore with an inner diameter and a central longitudinal axis, a camming device, an actuator member located below the tubular assembly, having a dual-bore configuration, the actuator member including a first bore, a second bore, and a concave seating surface formed within the second bore for receiving a obstructing device, wherein the first bore and the second bore are oriented 90 degrees to one another so that fluid may flow through the actuator while it is in either a first or a second position, and a stationary sleeve concentrically disposed between the actuator member and the elongated body.
- embodiments disclosed herein relate to a method of operating a downhole tool for providing a pressure differential between sub-assemblies, the method including running a downhole setting tool to a desired location in a wellbore, the downhole tool including an elongated body, a tubular assembly disposed within the elongated body, the tubular assembly further including a central flowbore with an inner diameter, and a central longitudinal axis, a camming device, an actuator member having a dual-bore configuration, the actuator member further including a first bore, a second bore, a concave seating surface formed within the second bore for receiving an obstructing device, and a stationary sleeve disposed between the actuator member and the elongated body, wherein the actuator member is aligned axially in a first position and located below the tubular assembly, circulating a fluid through the central flowbore, disposing the obstructing device into the fluid, wherein the fluid guides the obstructing device into the seating
- FIG. 1 is a partial cross-sectional side-view of a downhole tool in accordance with embodiments of the present disclosure.
- FIG. 2 is a cross-sectional view of an actuator member in accordance with embodiments of the present disclosure.
- FIG. 3 is a cross-sectional view of a sliding sleeve assembly in accordance with embodiments of the present disclosure.
- FIG. 4A is a cross-sectional view of an actuator member and a camming device in accordance with embodiments of the present disclosure.
- FIG. 4B is a side view of the actuator member and camming device of FIG. 4A in accordance with embodiments of the present disclosure
- FIG. 5 is a cross-sectional view of the actuator member in a first position in accordance with embodiments of the present disclosure.
- FIG. 6 is a cross-sectional view of the actuator member in a second position in accordance with embodiments of the present disclosure.
- FIG. 7 is a perspective view of an actuator member and camming device in a first position in accordance with embodiments of the present disclosure.
- FIG. 9 is a perspective view of an actuator member and camming device in a second position in accordance with embodiments of the present disclosure.
- FIG. 10 is close-up perspective view of the actuator member and camming device of FIG. 9 .
- Embodiments disclosed herein may provide a downhole tool for creating a pressure differential between two sub-assemblies.
- a downhole tool having a dual-bore configuration that restricts flow of a fluid through a first bore when the downhole tool is in a closed position, and allows fluid flow through a second bore when the tool is in an open position.
- the closed position may refer to a positioning of components in the downhole tool wherein fluid flow through the downhole tool is restricted or prevented.
- the downhole tool includes a camming device configured to rotate an actuator member to align one of the first and second bores with a central bore of the downhole tool.
- the pressure differential between sub-assemblies is achieved by dropping a restricting device into the first bore.
- the downhole tool When desired, the downhole tool is activated by increasing a downhole pressure until it exceeds a pre-determined value. Once the downhole tool is activated, the actuator member is rotated to the open (full-bore) position. In the open position, a full-bore diameter fluid flow may be reestablished and other downhole tools may be passed through the downhole tool.
- the downhole tool 1 may be used to provide a pressure differential between an upper subassembly 2 and a lower subassembly 3 .
- the downhole tool 1 includes an elongated body 10 and a tubular assembly 12 disposed within the elongated body 10 .
- the elongated body 10 may include a first cylindrical housing 70 , and a second cylindrical housing 72 .
- the elongated body 10 may include a coupler 74 that couples the first cylindrical housing 70 to the second cylindrical housing 72 .
- the downhole tool 1 may also include an energizer 76 , such as a biased spring. As shown, the energizer 76 may be disposed concentrically between the first cylindrical housing 70 and a portion of the tubular assembly 12 , and in contact with a lower portion of an upper sub 2 .
- the tubular assembly 12 includes a central flowbore 14 having an inner diameter 16 and a central longitudinal axis 18 .
- the size of the inner diameter 16 of the central flowbore 14 may vary based on, for example, the size and orientation of the wellbore, the size of components run through the central flowbore 14 , desired flow rate of fluid through the downhole tool, etc.
- the inner diameter 16 of the downhole tool may be between 1 and 4 inches.
- An actuator member 22 is disposed below tubular assembly 12 and configured to rotate from a first position to a second position within the downhole tool 1 .
- Actuator member 22 has a dual-bore configuration and includes a first bore 26 and a second bore 24 , wherein the first bore 26 and the second bore 24 are misaligned.
- the first bore 26 may be perpendicular to the second bore 24 . More specifically, the first bore 26 and the second bore 24 may be longitudinally aligned but oriented at 90 degrees to each other.
- the first bore 26 has a first inner diameter 17 substantially equal to inner diameter 16 of tubular assembly 12 and a second inner diameter 27 that is less than the inner diameter 16 of tubular assembly 12 .
- the first bore 26 may be referred to as a restricted bore.
- the second bore 24 has an inner diameter 23 substantially equal to the inner diameter 16 of the central flowbore 14 of tubular assembly 12 .
- second bore 24 may be referred to as a full bore.
- the actuator member 22 may be positioned within the tubular assembly 12 in the closed position, wherein the first bore 26 , or restricted bore, is aligned with the central flowbore 14 , such that fluid flow through the downhole tool 1 is restricted or prevented (i.e., when a drop ball is seated within the actuator member 22 , as described in more detail below).
- the actuator member 22 may be positioned within the tubular assembly 12 in the open position, wherein the second bore 24 is aligned with the central flowbore 14 , such that full-bore fluid flow is allowed through the downhole tool 1 .
- the first bore 26 includes a transition inner diameter 13 which tapers inward from the first inner diameter 17 to the second inner diameter 27 at an angle ⁇ .
- the angle ⁇ may be in the range of 0 to 60 degrees. In certain embodiments, angle ⁇ may be 30 degrees.
- the transition inner diameter 13 may be a concave surface sloping inwardly from the first inner diameter 17 to second inner diameter 17 . In certain embodiments, the transition inner diameter 13 of first bore 26 may provide a conical surface.
- a throat 25 or narrowed portion of the first bore 26 having the second inner diameter 27 , is formed in a lower portion of the first bore 26 . The throat 25 restricts fluid flow through the downhole tool 1 .
- a ball seat 15 is provided by the throat 25 and transition inner diameter 13 of first bore 26 .
- the ball seat 15 includes a concave surface configured to receive and seat an obstructing device 30 .
- the ball seat 15 may be a conical surface configured to receive and seat the obstructing device 30 .
- the obstructing device 30 or drop ball, is carried into the downhole tool 1 by the fluid flow, the drop ball 30 moves into the actuator member 22 , and seats in the ball seat 15 .
- the concave surface of the ball seat 15 formed by the transition inner diameter 13 and throat 25 of the first bore 26 , guides the drop ball 30 in position for proper seating in the ball seat 15 .
- the second bore 24 is a substantially full-bore, such that fluids and other devices may pass unimpeded through the downhole tool 1 when the actuator member 22 is rotated to the open position (i.e., when the second bore 24 is aligned with the central flowbore 14 ).
- Actuator member 22 may be rotated within downhole tool 1 by a camming device 20 , described in more detail below.
- Spherical seats may be provided on surfaces adjacent to the actuator member 22 to direct fluid flow through the actuator member 22 .
- the spherical seats (not shown) may be formed from a hard material, such as metal.
- a “soft seal” may be provided by an elastomer (e.g., o-ring) that seals against a lower face of the actuator member 22 .
- Downhole tool 1 may also include a sliding sleeve assembly 60 (shown in more detail in FIG. 3 ) disposed within the elongated body 10 and at least partially located below the actuator member 22 .
- a frangible connection 62 secures the sliding sleeve assembly 60 in place to maintain the actuator member 22 in a first, or closed, position.
- the frangible connection 62 may be, for example, shear screws or any other frangible connection known to a person of ordinary skill in the art.
- the frangible connection 62 may be a shearing device configured to shear by hydraulic activation.
- the shearing device may be a shear screw having a pre-determined shear force, such that the shear screw may shear when the applied pressure exceeds a specific value.
- the shear screw may shear when the pressure applied is between 300 and 4,000 psi.
- the downhole tool 1 may also include a stationary sleeve 34 concentrically disposed between the actuator member 22 and the elongated body 10 .
- the stationary sleeve 34 may be a control arm.
- the camming device 20 engages the actuator member 22 with the stationary sleeve 34 .
- the camming device 20 may include a plurality of inwardly facing camming pins 40 disposed on an inner surface 42 of the stationary sleeve 34 .
- the camming pins 40 may be located oppositely from one another at an equal radial distance r 1 from a point on the central longitudinal axis 18 .
- the camming device 20 may also include a plurality of corresponding cam slots 44 disposed on an outer surface the actuator member 22 for slidably engaging the plurality of camming pins 40 , and a plurality of outwardly facing protrusions 46 oppositely disposed on an exterior 48 of the actuator member 22 .
- the protrusions 46 may be located at an equal radial distance r 2 from a center point 47 along an axis of rotation 32 .
- the camming device 20 may include a plurality of holding grooves 50 disposed within the stationary sleeve 34 for mating with the protrusions 46 .
- the protrusions 46 may be maintained within the holding grooves 50 , such that the actuator member 22 may translate axially downward.
- the actuator member 22 may further include a mechanical stop to prevent the actuator member 22 from over-rotating during actuation.
- the downhole tool 1 is shown in closed and open positions, respectively.
- the actuator member 22 is oriented in the closed position ( FIG. 5 ).
- the first bore 26 is aligned with the central flowbore 14 .
- Fluid is provided through the central flowbore 14 of the downhole tool 1 .
- an obstructing device 30 i.e., a drop ball
- the obstructing device 30 may include one or more drop balls.
- fluid flow may be in a range of between 1 and 15 bbls/min; however, one of ordinary skill in the art will appreciate that other flow rates may be used depending on the particular application.
- fluid flow carries the obstructing device 30 into the actuator member 22 , wherein the obstructing device 30 is seated in the ball seat 28 .
- the concave surface provided by the transition inner diameter 13 guides the obstructing device 30 into position in the restricted lower portion of first bore 26 of actuator member 22 and maintains the obstructing device in position during actuation of other hydraulically actuated mechanisms.
- the seated obstructing device 30 prevents the flow of fluid through the downhole tool 1 . Accordingly, a pressure differential between the upper assembly (not shown) and the lower assembly (not shown) is created. Fluid may then flow upward and into channels (not shown) for providing fluid flow to hydraulically actuated mechanisms (e.g., a liner hanger).
- hydraulically actuated mechanisms e.g., a line
- fluid flow through the central flowbore 14 may be restored by activation of actuator member 22 .
- the actuator member 22 may be hydraulically activated by increasing the fluid pressure above the actuator member 22 acting on the obstructing device 30 and the concave surface of the ball seat 28 .
- the pressure differential created by the restricted fluid flow across the actuator member 22 provides a force on the sliding sleeve assembly 60 .
- the frangible connection 62 breaks.
- the shear pin s shear when the force acting on the sliding sleeve assembly 60 exceeds the shearing strength of the at least one shear pin.
- the frangible connection 62 is broken, the sliding sleeve assembly 60 moves downwardly, thereby allowing the actuator member 22 to move downward and rotate due to engagement of the camming device 20 .
- the actuator member 22 moves downwardly, it rotates from the first, closed, position, to the second, open, position ( FIG. 6 ).
- the camming device 20 causes the actuator member 22 to rotate from the first position ( FIG. 5 ) to the second position ( FIG. 6 ) around an axis of rotation 32 perpendicular to the central longitudinal axis 18 .
- corresponding camming slots ( 44 in FIG. 4A ) of the actuator member 22 engage camming pins ( 40 in FIG. 4A )
- a torque is imparted to the actuator member that causes it to rotate 90 degrees from the closed position to the open position.
- the stop mechanism (not shown) is placed a selected distance from the center of rotation of the actuator member 22 approximately equal to a distance of the camming pins ( 40 in FIG. 4A ) from the center of rotation of the actuator member 22 .
- stop mechanism (not shown) may be positioned between 45 degrees and 180 degrees from the camming slots ( 44 in FIG. 4A ) to prevent over-rotation of the main ball and obstruction of the bore.
- the energizer ( 76 in FIG. 1 ) may exert a downward force upon the shoulder ( 80 in FIG. 1 ) of the tubular assembly 12 to maintain the actuator member 22 in the second position once the actuator member 22 has rotated, thereby providing full-bore flow through the downhole tool 1 .
- FIGS. 7-10 perspective views of an actuator member and corresponding camming device of a downhole tool formed in accordance with embodiments of the present disclosure are shown.
- actuator member 122 is shown in a first position (i.e., closed position.).
- a first bore 126 in FIG. 9
- restricted bore is aligned with the central flowbore 114 , such that fluid flow through the downhole tool 100 is restricted or prevented (i.e., when a drop ball is seated within the actuator member 122 , as described in detail above).
- Actuator member 122 may be rotated within downhole tool 100 from the first position to a second position (i.e., open position) by a camming device 120 .
- a second position i.e., open position
- a second bore 124 is aligned with the central flowbore 114 , such that full-bore fluid flow is allowed through the downhole tool 100 .
- Downhole tool 100 may also include a sliding sleeve assembly 160 at least partially located below the actuator member 122 .
- a frangible connection (not shown) secures the sliding sleeve assembly 160 in place to maintain the actuator member 122 in the first, or closed, position.
- the downhole tool 100 may also include a stationary sleeve 134 concentrically disposed between the actuator member 122 and an elongated body (not shown).
- the stationary sleeve 134 may be a control arm.
- the camming device 120 engages the actuator member 122 with the stationary sleeve 134 .
- the camming device 120 may include a plurality of inwardly facing camming pins 140 disposed on an inner surface of the stationary sleeve 134 .
- the camming device 120 may also include a plurality of corresponding cam slots 144 disposed on an outer surface of the actuator member 122 for slidably engaging the plurality of camming pins 140 , and a plurality of outwardly facing protrusions 146 oppositely disposed on an outer surface of the actuator member 122 .
- the camming device 120 may include a plurality of holding grooves 150 disposed within the stationary sleeve 134 for mating with the protrusions 146 .
- the protrusions 146 may be maintained within the holding grooves 150 , such that the actuator member 122 may translate axially downward (indicated by directional arrow D).
- the actuator member 122 may further include a mechanical stop (not shown) to prevent the actuator member 22 from over-rotating during actuation.
- the actuator member 122 when the downhole tool 100 is lowered into the wellbore (not shown), the actuator member 122 is oriented in the first position ( FIGS. 7 and 8 ). Thus, the first bore 126 is aligned with the central flowbore 114 . Restricted fluid may then be provided through the central flowbore 114 of the downhole tool 100 .
- an obstructing device i.e., a drop ball, not shown
- the obstructing device 30 may include one or more drop balls.
- the fluid flow carries the obstructing device (not shown) into the actuator member 122 , wherein the obstructing device (not shown) is seated in the ball seat (not shown).
- a concave surface of the ball seat (not shown) guides the obstructing device (not shown) into position in the restricted lower portion of first bore 126 of actuator member 122 and maintains the obstructing device in position during actuation of other hydraulically actuated mechanisms.
- the seated obstructing device (not shown) prevents the flow of fluid through the downhole tool 100 . Accordingly, a pressure differential between the upper assembly (not shown) and the lower assembly (not shown) is created. Fluid may then flow upward and into channels (not shown) for providing fluid flow to hydraulically actuated mechanisms (e.g., a liner hanger).
- fluid flow through the central flowbore 114 may be restored by activation of actuator member 122 .
- the actuator member 122 may be hydraulically activated by increasing the fluid pressure above the actuator member 122 acting on the seated obstructing device (not shown).
- the pressure differential created by the restricted fluid flow across the actuator member 122 provides a force on the sliding sleeve assembly 160 .
- the frangible connection breaks.
- the shear pin s shear when the force acting on the sliding sleeve assembly 160 exceeds the shearing strength of the at least one shear pin.
- the sliding sleeve assembly 160 moves downwardly (indicated at D), thereby allowing the actuator member 122 to move downward and rotate due to engagement of the camming device 120 , as discussed in more detail below.
- the actuator member 122 moves downwardly, it rotates from the first position (i.e., closed position) ( FIGS. 7 and 8 ) to the second position (i.e., open position) ( FIGS. 9 and 10 ).
- Embodiments disclosed herein may provide improved downhole tools and/or improved techniques for hydraulically activating downhole tools.
- embodiments disclosed herein may provide a more reliable setting tool for setting hydraulic liner hangers.
- the downhole tool and method disclosed herein may advantageously provide a multi-functional tool capable of setting liner hangers, while also providing an unobstructed path through the setting tool that may allow the passage of other tools, for example, cement wipers.
- the hydraulic liner hanger may be set and the liner cemented in a single operation.
- the tool may also advantageously be used for setting casing or isolation packers attached to the liner, or other mechanisms as desired.
- the downhole tool and method are especially useful in a deviated wellbore or horizontal wellbore, because the features disclosed herein may provide the ability to securely seat a drop ball within an actuator member, without the need for performing extraneous steps to properly seat the ball.
- embodiments disclosed herein advantageously provide ball seat location within an actuator member, which has a natural centering effect provided by an internal concave surface guides the drop ball into the seat. Further, embodiments disclosed herein do not require collet mechanisms, which often damage elastomers, plugs, or darts run through the tool.
Abstract
Description
- This application, pursuant to 35 U.S.C. §119(e), claims priority to U.S. Provisional Application Ser. No. 61/103,862, filed Oct. 8, 2008. That application is incorporated by reference in its entirety.
- 1. Field of the Invention
- Embodiments disclosed herein relate to downhole tools, particularly setting tools for hydraulic liners and other hydraulic actuated devices. More specifically, embodiments disclosed herein relate to setting tools that actuate hydraulic liner hangers in deviated wellbores.
- 2. Background Art
- Typically, liners are used below casing in wellbores to extend the length of the casing. A liner is a section of smaller casing that is suspended downhole in existing casing. In most cases, the liner extends downwardly into an open hole and overlaps the existing casing by approximately 200-400 ft. In certain application, the liner may be cemented in place. A conventional liner hanger is used to attach or hang liners from the internal wall of a casing segment. Hydraulic liner hangers have been preferred by operators in deviated wellbores over mechanical liner hangers. This is because deviation of the wellbore makes it less certain that the mechanical hanger mechanism will be properly actuated in a deviated wellbore. In this instance hydraulic liners provide advantages over mechanical hangers, because hydraulic hangers may not require mechanical movement of the pipe or tubular.
- In conventional designs, the liner with a setting tool is lowered into position, and pressure within the setting tool is used to set the hydraulic liner hanger through a lateral port therein. In some designs, the flow passage through the setting tool is obstructed at its lowermost end so the applied pressure in the setting tool properly reaches the hydraulic liner hanger. Other designs place the obstruction for the setting tool near the bottom of the liner to allow a cement wiper plug to pass completely through the liner to remove residual cement therefrom. If the residual cement is not removed, cutting or grinding operations may be required to remove excess cement within the liner.
- Some aspects of using a conventional setting tool may lengthen the time required to complete the placement and cementing of a liner. In addition to an increase in completion time, other setting tool designs are subject to inadvertent damage within the tool. For example, collet-type valve seats have been used in applications where the drop ball seats on relatively short upwardly directed collet fingers, thus compressing the collet fingers when the ball is seated. A shear pin release permits a shift of the fingers to a location where the collet fingers are expanded to release the ball member. The collet fingers are typically short, thereby preventing the compressive forces from damaging them. (The design, thus, requires that the fingers have little resilience and prevents them from fully expanding unless a large diameter ball is used. In addition to damaging the tool, using a large diameter ball raises the possibility of prematurely actuating a wiper plug upon release.) A collet mechanism is also prone to damaging fins of a pump-down plug or dart by folding the fins backwards as they pass through the unsupported slots of the collet. Additionally, fluid cuts as it passes around the fins and through the slots.
- In a system where the end of the liner with a setting tool is located in a non-vertical location, such as a deviated or horizontal section of well bore, other problems arise. In these instances it can be extremely difficult, and sometimes not possible, to obtain seating of a ball or an obstructing device in a small, centrally located valve seat opening at the lower end of a liner. In such a design, the valve seat has a convex upper surface, as shown in, for example, U.S. Pat. No. 5,553,672. In this design, as the ball rolls along the inner diameter of the tool, gravity may move the ball into a dead fluid area that is adjacent to the seat. In order to seat the drop ball, the ball must be lifted off of the low side of the tool and moved to the center of the valve with the fluid flow. This process can be time constraining and difficult to accomplish.
- Accordingly, there exists a need for a setting tool that provides a pressure differential for actuating downhole tools that includes an improved ball valve assembly.
- In one aspect, embodiments disclosed herein relate to a downhole tool for providing a pressure differential between sub-assemblies, the downhole tool including an elongated body, a tubular assembly disposed within the elongated body, the tubular assembly including a central flowbore with an inner diameter and a central longitudinal axis, a camming device, an actuator member located below the tubular assembly, having a dual-bore configuration, the actuator member including a first bore, a second bore, and a concave seating surface formed within the second bore for receiving a obstructing device, wherein the first bore and the second bore are oriented 90 degrees to one another so that fluid may flow through the actuator while it is in either a first or a second position, and a stationary sleeve concentrically disposed between the actuator member and the elongated body.
- In another aspect, embodiments disclosed herein relate to a method of operating a downhole tool for providing a pressure differential between sub-assemblies, the method including running a downhole setting tool to a desired location in a wellbore, the downhole tool including an elongated body, a tubular assembly disposed within the elongated body, the tubular assembly further including a central flowbore with an inner diameter, and a central longitudinal axis, a camming device, an actuator member having a dual-bore configuration, the actuator member further including a first bore, a second bore, a concave seating surface formed within the second bore for receiving an obstructing device, and a stationary sleeve disposed between the actuator member and the elongated body, wherein the actuator member is aligned axially in a first position and located below the tubular assembly, circulating a fluid through the central flowbore, disposing the obstructing device into the fluid, wherein the fluid guides the obstructing device into the seating surface, and providing a pressure differential between an upper sub and a lower sub to activate the downhole tool.
- Other aspects and advantages of the invention will be apparent from the following description and the appended claims.
-
FIG. 1 is a partial cross-sectional side-view of a downhole tool in accordance with embodiments of the present disclosure. -
FIG. 2 is a cross-sectional view of an actuator member in accordance with embodiments of the present disclosure. -
FIG. 3 is a cross-sectional view of a sliding sleeve assembly in accordance with embodiments of the present disclosure. -
FIG. 4A is a cross-sectional view of an actuator member and a camming device in accordance with embodiments of the present disclosure. -
FIG. 4B is a side view of the actuator member and camming device ofFIG. 4A in accordance with embodiments of the present disclosure -
FIG. 5 is a cross-sectional view of the actuator member in a first position in accordance with embodiments of the present disclosure. -
FIG. 6 is a cross-sectional view of the actuator member in a second position in accordance with embodiments of the present disclosure. -
FIG. 7 is a perspective view of an actuator member and camming device in a first position in accordance with embodiments of the present disclosure. -
FIG. 8 is a close-up perspective view of the actuator member and camming device ofFIG. 7 . -
FIG. 9 is a perspective view of an actuator member and camming device in a second position in accordance with embodiments of the present disclosure. -
FIG. 10 is close-up perspective view of the actuator member and camming device ofFIG. 9 . - Embodiments disclosed herein may provide a downhole tool for creating a pressure differential between two sub-assemblies. In particular, a downhole tool having a dual-bore configuration that restricts flow of a fluid through a first bore when the downhole tool is in a closed position, and allows fluid flow through a second bore when the tool is in an open position is disclosed. As used herein, the closed position may refer to a positioning of components in the downhole tool wherein fluid flow through the downhole tool is restricted or prevented. The downhole tool includes a camming device configured to rotate an actuator member to align one of the first and second bores with a central bore of the downhole tool. The pressure differential between sub-assemblies is achieved by dropping a restricting device into the first bore. When desired, the downhole tool is activated by increasing a downhole pressure until it exceeds a pre-determined value. Once the downhole tool is activated, the actuator member is rotated to the open (full-bore) position. In the open position, a full-bore diameter fluid flow may be reestablished and other downhole tools may be passed through the downhole tool.
- Referring initially to
FIG. 1 , a downhole tool 1 in accordance with the present disclosure is shown. The downhole tool 1 may be used to provide a pressure differential between anupper subassembly 2 and alower subassembly 3. The downhole tool 1 includes anelongated body 10 and atubular assembly 12 disposed within theelongated body 10. Theelongated body 10 may include a firstcylindrical housing 70, and a secondcylindrical housing 72. In this embodiment, theelongated body 10 may include acoupler 74 that couples the firstcylindrical housing 70 to the secondcylindrical housing 72. The downhole tool 1 may also include anenergizer 76, such as a biased spring. As shown, theenergizer 76 may be disposed concentrically between the firstcylindrical housing 70 and a portion of thetubular assembly 12, and in contact with a lower portion of anupper sub 2. - Referring to
FIGS. 1 and 2 , thetubular assembly 12 includes acentral flowbore 14 having aninner diameter 16 and a centrallongitudinal axis 18. One of ordinary skill in the art will appreciate that the size of theinner diameter 16 of thecentral flowbore 14 may vary based on, for example, the size and orientation of the wellbore, the size of components run through thecentral flowbore 14, desired flow rate of fluid through the downhole tool, etc. In certain embodiments, theinner diameter 16 of the downhole tool may be between 1 and 4 inches. - An
actuator member 22 is disposed belowtubular assembly 12 and configured to rotate from a first position to a second position within the downhole tool 1. Ashoulder 82 formed on the lower end oftubular assembly 12 contacts an upper end ofactuator member 22.Actuator member 22 has a dual-bore configuration and includes afirst bore 26 and asecond bore 24, wherein thefirst bore 26 and thesecond bore 24 are misaligned. In particular, in one embodiment, thefirst bore 26 may be perpendicular to thesecond bore 24. More specifically, thefirst bore 26 and thesecond bore 24 may be longitudinally aligned but oriented at 90 degrees to each other. - Referring to
FIG. 2 , thefirst bore 26 has a firstinner diameter 17 substantially equal toinner diameter 16 oftubular assembly 12 and a secondinner diameter 27 that is less than theinner diameter 16 oftubular assembly 12. Thus, thefirst bore 26 may be referred to as a restricted bore. Thesecond bore 24 has aninner diameter 23 substantially equal to theinner diameter 16 of thecentral flowbore 14 oftubular assembly 12. Thus, second bore 24 may be referred to as a full bore. Theactuator member 22 may be positioned within thetubular assembly 12 in the closed position, wherein thefirst bore 26, or restricted bore, is aligned with thecentral flowbore 14, such that fluid flow through the downhole tool 1 is restricted or prevented (i.e., when a drop ball is seated within theactuator member 22, as described in more detail below). Alternatively, theactuator member 22 may be positioned within thetubular assembly 12 in the open position, wherein thesecond bore 24 is aligned with thecentral flowbore 14, such that full-bore fluid flow is allowed through the downhole tool 1. - The
first bore 26, or restricted bore, includes a transitioninner diameter 13 which tapers inward from the firstinner diameter 17 to the secondinner diameter 27 at an angle α. In one embodiment, the angle α may be in the range of 0 to 60 degrees. In certain embodiments, angle α may be 30 degrees. In some embodiments, the transitioninner diameter 13 may be a concave surface sloping inwardly from the firstinner diameter 17 to secondinner diameter 17. In certain embodiments, the transitioninner diameter 13 offirst bore 26 may provide a conical surface. Athroat 25, or narrowed portion of thefirst bore 26 having the secondinner diameter 27, is formed in a lower portion of thefirst bore 26. Thethroat 25 restricts fluid flow through the downhole tool 1. Aball seat 15 is provided by thethroat 25 and transitioninner diameter 13 offirst bore 26. Theball seat 15 includes a concave surface configured to receive and seat an obstructingdevice 30. In one embodiment, theball seat 15 may be a conical surface configured to receive and seat the obstructingdevice 30. When the obstructingdevice 30, or drop ball, is carried into the downhole tool 1 by the fluid flow, thedrop ball 30 moves into theactuator member 22, and seats in theball seat 15. The concave surface of theball seat 15, formed by the transitioninner diameter 13 andthroat 25 of thefirst bore 26, guides thedrop ball 30 in position for proper seating in theball seat 15. A concave or conical surface allows for obstructingdevices 30 of various sizes to be used. Additionally, the concave surface of theball seat 15 helps maintain the proper positioning of thedrop ball 30 in deviated wells and horizontal wells. Fluid pressure may be applied above thedrop ball 30 to facilitate the pressure actuation of downhole tools, such as liner hangers or packers. - The
second bore 24 is a substantially full-bore, such that fluids and other devices may pass unimpeded through the downhole tool 1 when theactuator member 22 is rotated to the open position (i.e., when thesecond bore 24 is aligned with the central flowbore 14).Actuator member 22 may be rotated within downhole tool 1 by acamming device 20, described in more detail below. Spherical seats (not shown) may be provided on surfaces adjacent to theactuator member 22 to direct fluid flow through theactuator member 22. In one embodiment, the spherical seats (not shown) may be formed from a hard material, such as metal. Alternatively, a “soft seal” may be provided by an elastomer (e.g., o-ring) that seals against a lower face of theactuator member 22. - Downhole tool 1 may also include a sliding sleeve assembly 60 (shown in more detail in
FIG. 3 ) disposed within theelongated body 10 and at least partially located below theactuator member 22. Afrangible connection 62 secures the slidingsleeve assembly 60 in place to maintain theactuator member 22 in a first, or closed, position. Thefrangible connection 62 may be, for example, shear screws or any other frangible connection known to a person of ordinary skill in the art. Alternatively, thefrangible connection 62 may be a shearing device configured to shear by hydraulic activation. For example, the shearing device may be a shear screw having a pre-determined shear force, such that the shear screw may shear when the applied pressure exceeds a specific value. In another example, the shear screw may shear when the pressure applied is between 300 and 4,000 psi. - As shown in
FIG. 2 , the slidingsleeve assembly 60 may include alower section 59 coupled to anupper section 61 by any means known in the art, such as, threaded engagement, welding, bolting, etc. The slidingsleeve assembly 60 may be configured such that anupper end 59 a of thelower section 59 and anupper end 61 a of theupper section 61 are both in contact with alower surface 22 a of theactuator member 22. The slidingsleeve assembly 60 may support or maintain theactuator member 22 in the closed position. Additionally, multiple o-rings 90 may be disposed within the tool for providing seals between various components. - Referring to
FIGS. 2 , 3, 4A, and 4B, the downhole tool 1 may also include astationary sleeve 34 concentrically disposed between theactuator member 22 and theelongated body 10. In one embodiment, thestationary sleeve 34 may be a control arm. Thecamming device 20 engages theactuator member 22 with thestationary sleeve 34. Thecamming device 20 may include a plurality of inwardly facing camming pins 40 disposed on aninner surface 42 of thestationary sleeve 34. The camming pins 40 may be located oppositely from one another at an equal radial distance r1 from a point on the centrallongitudinal axis 18. Thecamming device 20 may also include a plurality ofcorresponding cam slots 44 disposed on an outer surface theactuator member 22 for slidably engaging the plurality of camming pins 40, and a plurality of outwardly facingprotrusions 46 oppositely disposed on anexterior 48 of theactuator member 22. Theprotrusions 46 may be located at an equal radial distance r2 from acenter point 47 along an axis ofrotation 32. Thecamming device 20 may include a plurality of holdinggrooves 50 disposed within thestationary sleeve 34 for mating with theprotrusions 46. During actuation of theactuator member 22, theprotrusions 46 may be maintained within the holdinggrooves 50, such that theactuator member 22 may translate axially downward. Theactuator member 22 may further include a mechanical stop to prevent theactuator member 22 from over-rotating during actuation. - Referring now to
FIGS. 5 and 6 , the downhole tool 1 is shown in closed and open positions, respectively. When the downhole tool 1 is lowered into the wellbore (not shown), theactuator member 22 is oriented in the closed position (FIG. 5 ). Thus, thefirst bore 26 is aligned with thecentral flowbore 14. Fluid is provided through thecentral flowbore 14 of the downhole tool 1. When actuation of a downhole mechanism, for example, a liner hanger, is desired, an obstructing device 30 (i.e., a drop ball) may be provided in the fluid flow. In certain embodiments, the obstructingdevice 30 may include one or more drop balls. The fluid flow may be in a range of between 1 and 15 bbls/min; however, one of ordinary skill in the art will appreciate that other flow rates may be used depending on the particular application. When actuation is desired, fluid flow carries the obstructingdevice 30 into theactuator member 22, wherein the obstructingdevice 30 is seated in theball seat 28. The concave surface provided by the transitioninner diameter 13 guides the obstructingdevice 30 into position in the restricted lower portion offirst bore 26 ofactuator member 22 and maintains the obstructing device in position during actuation of other hydraulically actuated mechanisms. The seated obstructingdevice 30 prevents the flow of fluid through the downhole tool 1. Accordingly, a pressure differential between the upper assembly (not shown) and the lower assembly (not shown) is created. Fluid may then flow upward and into channels (not shown) for providing fluid flow to hydraulically actuated mechanisms (e.g., a liner hanger). - After actuation of at least one other hydraulic mechanism, fluid flow through the
central flowbore 14 may be restored by activation ofactuator member 22. Theactuator member 22 may be hydraulically activated by increasing the fluid pressure above theactuator member 22 acting on the obstructingdevice 30 and the concave surface of theball seat 28. The pressure differential created by the restricted fluid flow across theactuator member 22 provides a force on the slidingsleeve assembly 60. When the force on the sliding sleeve assembly exceeds the predetermined value, or shear value, of thefrangible connection 62, thefrangible connection 62 breaks. For example, in the embodiment where thefrangible connection 62 includes at least one shear pin, the shear pins shear when the force acting on the slidingsleeve assembly 60 exceeds the shearing strength of the at least one shear pin. When thefrangible connection 62 is broken, the slidingsleeve assembly 60 moves downwardly, thereby allowing theactuator member 22 to move downward and rotate due to engagement of thecamming device 20. As theactuator member 22 moves downwardly, it rotates from the first, closed, position, to the second, open, position (FIG. 6 ). - The
camming device 20 causes theactuator member 22 to rotate from the first position (FIG. 5 ) to the second position (FIG. 6 ) around an axis ofrotation 32 perpendicular to the centrallongitudinal axis 18. When corresponding camming slots (44 inFIG. 4A ) of theactuator member 22 engage camming pins (40 inFIG. 4A ), a torque is imparted to the actuator member that causes it to rotate 90 degrees from the closed position to the open position. The stop mechanism (not shown) is placed a selected distance from the center of rotation of theactuator member 22 approximately equal to a distance of the camming pins (40 inFIG. 4A ) from the center of rotation of theactuator member 22. Further, stop mechanism (not shown) may be positioned between 45 degrees and 180 degrees from the camming slots (44 inFIG. 4A ) to prevent over-rotation of the main ball and obstruction of the bore. - The energizer (76 in
FIG. 1 ) may exert a downward force upon the shoulder (80 inFIG. 1 ) of thetubular assembly 12 to maintain theactuator member 22 in the second position once theactuator member 22 has rotated, thereby providing full-bore flow through the downhole tool 1. - Referring now to
FIGS. 7-10 , perspective views of an actuator member and corresponding camming device of a downhole tool formed in accordance with embodiments of the present disclosure are shown. Referring initially toFIGS. 7 and 8 ,actuator member 122 is shown in a first position (i.e., closed position.). In the first position, a first bore (126 inFIG. 9 ), or restricted bore, is aligned with thecentral flowbore 114, such that fluid flow through thedownhole tool 100 is restricted or prevented (i.e., when a drop ball is seated within theactuator member 122, as described in detail above).Actuator member 122 may be rotated withindownhole tool 100 from the first position to a second position (i.e., open position) by acamming device 120. In the second position, asecond bore 124 is aligned with thecentral flowbore 114, such that full-bore fluid flow is allowed through thedownhole tool 100. -
Downhole tool 100 may also include a slidingsleeve assembly 160 at least partially located below theactuator member 122. A frangible connection (not shown) secures the slidingsleeve assembly 160 in place to maintain theactuator member 122 in the first, or closed, position. Thedownhole tool 100 may also include astationary sleeve 134 concentrically disposed between theactuator member 122 and an elongated body (not shown). In one embodiment, thestationary sleeve 134 may be a control arm. Thecamming device 120 engages theactuator member 122 with thestationary sleeve 134. Thecamming device 120 may include a plurality of inwardly facing camming pins 140 disposed on an inner surface of thestationary sleeve 134. Thecamming device 120 may also include a plurality ofcorresponding cam slots 144 disposed on an outer surface of theactuator member 122 for slidably engaging the plurality of camming pins 140, and a plurality of outwardly facingprotrusions 146 oppositely disposed on an outer surface of theactuator member 122. Further, thecamming device 120 may include a plurality of holdinggrooves 150 disposed within thestationary sleeve 134 for mating with theprotrusions 146. During actuation of theactuator member 122, theprotrusions 146 may be maintained within the holdinggrooves 150, such that theactuator member 122 may translate axially downward (indicated by directional arrow D). Theactuator member 122 may further include a mechanical stop (not shown) to prevent theactuator member 22 from over-rotating during actuation. - Still referring to
FIGS. 7-10 , when thedownhole tool 100 is lowered into the wellbore (not shown), theactuator member 122 is oriented in the first position (FIGS. 7 and 8 ). Thus, thefirst bore 126 is aligned with thecentral flowbore 114. Restricted fluid may then be provided through thecentral flowbore 114 of thedownhole tool 100. When actuation of a downhole mechanism, for example, a liner hanger, is desired, an obstructing device (i.e., a drop ball, not shown) may be provided in the fluid flow. In certain embodiments, the obstructingdevice 30 may include one or more drop balls. The fluid flow carries the obstructing device (not shown) into theactuator member 122, wherein the obstructing device (not shown) is seated in the ball seat (not shown). A concave surface of the ball seat (not shown) guides the obstructing device (not shown) into position in the restricted lower portion offirst bore 126 ofactuator member 122 and maintains the obstructing device in position during actuation of other hydraulically actuated mechanisms. The seated obstructing device (not shown) prevents the flow of fluid through thedownhole tool 100. Accordingly, a pressure differential between the upper assembly (not shown) and the lower assembly (not shown) is created. Fluid may then flow upward and into channels (not shown) for providing fluid flow to hydraulically actuated mechanisms (e.g., a liner hanger). - After actuation of at least one hydraulic mechanism, fluid flow through the
central flowbore 114 may be restored by activation ofactuator member 122. Theactuator member 122 may be hydraulically activated by increasing the fluid pressure above theactuator member 122 acting on the seated obstructing device (not shown). The pressure differential created by the restricted fluid flow across theactuator member 122 provides a force on the slidingsleeve assembly 160. When the force on the sliding sleeve assembly exceeds the predetermined value, or shear value, of the frangible connection (not shown), the frangible connection (not shown) breaks. For example, in the embodiment where the frangible connection (not shown) includes at least one shear pin, the shear pins shear when the force acting on the slidingsleeve assembly 160 exceeds the shearing strength of the at least one shear pin. When the frangible connection (not shown) is broken, the slidingsleeve assembly 160 moves downwardly (indicated at D), thereby allowing theactuator member 122 to move downward and rotate due to engagement of thecamming device 120, as discussed in more detail below. As theactuator member 122 moves downwardly, it rotates from the first position (i.e., closed position) (FIGS. 7 and 8 ) to the second position (i.e., open position) (FIGS. 9 and 10 ). - The
camming device 120 allows theactuator member 122 to rotate from the first position (FIGS. 7 and 8 ) to the second position (FIGS. 9 and 10 ) around an axis of rotation (not shown) perpendicular to a central longitudinal axis of thedownhole tool 100. When correspondingcamming slots 144 of theactuator member 122 engagecamming pins 140 as theactuator member 122 is moving downwardly (indicated at D), a torque is imparted to theactuator member 122 that causes it to rotate 90 degrees from the first position to the second position.Protrusions 146 engaged with holdinggrooves 150 of slidingsleeve 134 guide theactuator member 122 downward as theactuator member 122 rotates. The stop mechanism (not shown) may be positioned between 45 degrees and 180 degrees from thecamming slots 144 to prevent over-rotation of the main ball and obstruction of the bore. - Embodiments disclosed herein may provide improved downhole tools and/or improved techniques for hydraulically activating downhole tools. In particular, embodiments disclosed herein may provide a more reliable setting tool for setting hydraulic liner hangers. The downhole tool and method disclosed herein may advantageously provide a multi-functional tool capable of setting liner hangers, while also providing an unobstructed path through the setting tool that may allow the passage of other tools, for example, cement wipers. Also, advantageously, the hydraulic liner hanger may be set and the liner cemented in a single operation. The tool may also advantageously be used for setting casing or isolation packers attached to the liner, or other mechanisms as desired. The downhole tool and method are especially useful in a deviated wellbore or horizontal wellbore, because the features disclosed herein may provide the ability to securely seat a drop ball within an actuator member, without the need for performing extraneous steps to properly seat the ball. Particularly, embodiments disclosed herein advantageously provide ball seat location within an actuator member, which has a natural centering effect provided by an internal concave surface guides the drop ball into the seat. Further, embodiments disclosed herein do not require collet mechanisms, which often damage elastomers, plugs, or darts run through the tool.
- While the invention has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the invention as disclosed herein. Accordingly, the scope of the invention should be limited only by the attached claims.
Claims (20)
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CA2681987A CA2681987A1 (en) | 2008-10-08 | 2009-10-08 | Ball seat sub |
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